Transient Pressure Analysis: Finite Conductivity Fracture Case Versus Damaged Fracture Case

Cinco-Ley, Héber; Samaniego-V., F.

doi:10.2118/10179-ms

Cited by 179 publications

(31 citation statements)

References 19 publications

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“…A large number of studies have shown that when the vertical fractured well is in production state, it induces twodimensional elliptic seepage in the stratum and will form the conjugate isobaric elliptical equipotential line and hyperbola streamline group which uses the fractures endpoint as the main focus [20]. So it is more close to reality to use the elliptic coordinates to describe the vertical fractured well seepage physical process.…”

Section: Establishment Of the Mathematical Modelmentioning

confidence: 99%

Productivity Prediction Model of Vertical Artificial Fracture Well and Analysis of Influence Factor in Low Permeability Reservoir

Zhang¹,

Yin²,

Song³

2015

TOPEJ

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Abstract:Based on the analysis of seepage mechanism of fracturing wells in low permeability reservoir, this paper establishes the capacity model of the vertical fractured well production under the factors of Start-up pressure gradient, pressure sensitive effect and the artificial fracture length. The numerical simulation is compiled and software calculates the capacity model by using numerical simulation. This simulation technique verifies the validity of the model and numerical method. On this basis, we study the influence of the included angle of artificial fracture and well array direction, artificial fracture length, start-up pressure gradient and production pressure difference to the capacity of the oil well.Keywords: low permeability reservoirs; the capacity equation of the vertical fractured well; fracture length; start-up pressure gradient; well array direction.

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Section: Establishment Of the Mathematical Modelmentioning

confidence: 99%

Productivity Prediction Model of Vertical Artificial Fracture Well and Analysis of Influence Factor in Low Permeability Reservoir

Zhang¹,

Yin²,

Song³

2015

TOPEJ

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“…The early work of Fetkovich (1980) and Cinco-Ley and Meng (1981) and the more recent work of Blasingame et al (1991) and Agarwal et al (1999) includes information on type-curve analyses. Modern RTA can provide a number of sophisticated graphical techniques to identify flow regimes and model production profiles.…”

Section: Rate Transient Analysis (Rta) In Unconventional Reservoirsmentioning

confidence: 99%

Stimulated Reservoir Volume: A Misapplied Concept?

2014

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The interpretation of microseismic data was initially focused on hydraulic fracture length and height, providing an important measurement to calibrate planar fracture propagation models. However, microseismic data in the Barnett shale exhibited significantly more complex patterns compared to typical tight-gas sands. The concept of stimulated reservoir volume (SRV) was developed to provide some quantitative measure of stimulation effectiveness in the Barnett shale based on the size of the microseismic "cloud." SRV is now ubiquitous when discussing well performance and stimulation effectiveness in unconventional reservoirs. However, SRV and similar techniques provide little insight into two critical parameters: hydraulic fracture area and conductivity. Each of these can vary significantly based on geologic conditions and fracture treatment design. Hydraulic fracture area and fracture conductivity, combined with reservoir permeability, stress regime, and rock properties, control well performance, not SRV.The concept of SRV has spawned numerous reservoir engineering models to approximate the production mechanisms associated with complex hydraulic fractures and to facilitate production modeling and well performance evaluations (e.g., rate transient analysis). However, these reservoir engineering models are often divorced from the fracture mechanics that created the fracture network, a significant limitation when evaluating completion effectiveness. Additionally, the interpretation of the microseismic data and the calculation of SRV are poorly linked to the actual hydraulic fracture geometry and distribution of fracture conductivity. This paper presents detailed numerical reservoir simulations coupled with hydraulic fracture modeling that illustrates the limitations and potential misapplications of the SRV concept. This work shows that simplifying assumptions in many SRVbased rate transient models may lead to estimates of hydraulic fracture length and reservoir permeability that are not well suited for completion optimization. Two case histories are presented that illustrate the limitations of SRV-based well performance evaluations. The paper concludes that using microseismic images to estimate a SRV may not be sufficient for completion evaluation and optimization. However, the simple calculation of microseismic volume (MV) can provide significant insights to guide fracture and reservoir modeling endeavors.

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“…It is noted that Eq. A-10 is the definition for fracture face skin for a hydraulically fractured reservoir, as introduced by Cinco-Ley and Samaniego-V. (1981).…”

Section: ( ) Eq A-1mentioning

confidence: 99%

Analysis of Decline Curves Based on Beta Derivative

Shahamat

Mattar²,

Aguilera

2014

All Days

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This paper presents a new simplified method for forecasting oil and gas production during transient and boundary dominated flow (BDF), which does not require the use of complex analytical or numerical modeling tools. The method is based on the behaviour of the beta derivative (), where two approximate straight lines are obtained during transient flow and BDF with slopes and , respectively. The method is applicable not only to vertical wells in conventional reservoirs producing during BDF but also to hydraulically fractured vertical/multifractured horizontal wells in unconventional reservoirs with prevailing transient (linear) flow. Upon selection of an appropriate (which mainly depends upon the type of flow regime, i.e., radial or linear) and using the proposed equations, type curves can be generated that provide a convenient method for obtaining the slopes of beta derivatives for transient flow ( ) and BDF ( ) through a type curve matching process. The method is validated by comparing results against oil and gas numerical simulations of vertical and hydraulically fracture vertical wells.The developed method is not biased toward any flow regime or presence of skin. Flow regime and skin effects are embedded in the and parameters. Transient and BDF flow are accounted for through the slopes and , respectively. Corroborated with the use of numerical simulation, the proposed method provides reliable production rate forecasting while staying away from the complexities of analytical or numerical modeling.

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Transient Pressure Analysis: Finite Conductivity Fracture Case Versus Damaged Fracture Case

Cited by 179 publications

References 19 publications

Productivity Prediction Model of Vertical Artificial Fracture Well and Analysis of Influence Factor in Low Permeability Reservoir

Productivity Prediction Model of Vertical Artificial Fracture Well and Analysis of Influence Factor in Low Permeability Reservoir

Stimulated Reservoir Volume: A Misapplied Concept?

Analysis of Decline Curves Based on Beta Derivative

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